A system may include a monitoring device that receives data associated with one or more properties at a well. The monitoring device may determine a plurality of expected flow rates of hydrocarbons produced from the well with respect to a plurality of gas injection rates associated with the well based on the data and a hydrocarbon model. The hydrocarbon model may estimate the plurality of expected flow rates of hydrocarbons. The monitoring device may then adjust a gas injection rate at the well based on the plurality of expected flow rates of hydrocarbons.
Legal claims defining the scope of protection, as filed with the USPTO.
1. A system, comprising: a monitoring device configured to receive data associated with one or more properties at a well, wherein the monitoring device is configured to: determine a plurality of expected flow rates of hydrocarbons produced from the well with respect to a plurality of gas injection rates associated with the well based on a hydrocarbon model configured to estimate the plurality of expected flow rates of hydrocarbons; determine a current flow rate of hydrocarbons at the well based on the data and the hydrocarbon model; determine, based on the plurality of expected flow rates, a first range of flow rates that substantially maximizes a flow rate of hydrocarbons at the well, and a second range of gas injection rates that corresponds to the first range of flow rates; determine whether the current flow rate of hydrocarbons at the well is within the first range of flow rates; and adjust a gas injection rate at the well in response to the current flow rate of hydrocarbons at the well not being within the first range of flow rates, wherein adjusting the gas injection rate comprises sending one or more commands to one or more components associated with the well, wherein the one or more commands are configured to cause the one or more components to adjust the gas injection rate to be within the second range of gas injection rates.
2. The system of claim 1 , wherein the plurality of expected flow rates of hydrocarbons comprises a first expected flow rate that corresponds to a first flow rate of oil and water.
3. The system of claim 2 , wherein the plurality of expected flow rates of hydrocarbons comprises a second expected flow rate that corresponds to a second flow rate of oil.
4. The system of claim 1 , wherein the hydrocarbon model is configured to estimate multiphase properties of a flow of hydrocarbons at the well based on the data, wherein the multiphase properties comprise a first fraction of oil in the flow of hydrocarbons, a second fraction of water in the flow of hydrocarbons, and a third fraction of gas in the flow of hydrocarbons.
5. The system of claim 1 , wherein the data comprises tubing head pressure, tubing head temperature, casing head pressure, casing head temperature, flowline pressure, flowline temperature, choke size, a water fraction amount, an oil fraction amount, an oil density value, a gas density value, a water density value, or any combination thereof.
6. The system of claim 1 , wherein the plurality of expected flow rates of hydrocarbons produced from the well with respect to the plurality of gas injection rates is determined based on a simulation performed using the hydrocarbon model.
7. The system of claim 6 , wherein the monitoring device is configured to: plot a plurality of values on a graph based on the simulation; determine a mathematical function based on the plot; and determine the plurality of expected flow rates of hydrocarbons produced from the well with respect to the plurality of gas injection rates based on the mathematical function.
8. The system of claim 1 , wherein the current flow rate of hydrocarbons at the well corresponds to a flow rate of oil and water, and the monitoring device is configured to: determine a watercut level associated with the hydrocarbons at the well; determine a second current flow rate of hydrocarbons at the well based on the current flow rate, wherein the second current flow rate corresponds to a flow rate of oil; determine whether the current flow rate exceeds a first threshold; determine whether the second current flow rate exceeds a second threshold; and adjust the gas injection rate in response to the current flow rate not exceeding the first threshold or in response to the second current flow rate not exceeding the second threshold.
9. A system, comprising: a monitoring device configured to receive data associated with one or more properties at a well, wherein the monitoring device is configured to: determine a plurality of expected flow rates of hydrocarbons produced from a plurality of wells with respect to a plurality of gas injection rates based on the data, wherein each of the plurality of gas injection rates is associated with a respective one of the plurality of wells; determine a plurality of current flow rates of hydrocarbons based on the data, wherein each of the plurality of current flow rates is associated with a well of the plurality of wells; determine, based on the plurality of expected flow rates, a first plurality of ranges of flow rates, wherein each of the first plurality of ranges of flow rates is configured to substantially maximize a respective flow rate of the plurality of current flow rates; determine, based on the plurality of expected flow rates, a second plurality of ranges of gas injection rates that corresponds to the first plurality of ranges of flow rates, wherein each of the second plurality of ranges of gas injection rates corresponds to a respective range of flow rates of the first plurality of ranges of flow rates; determine whether a current flow rate of the plurality of current flow rates is within a range of flow rates of the first plurality of ranges of flow rates; and adjust a gas injection rate at the well in response to the current flow rate associated with the well not being within a range of flow rates of the first plurality of ranges of flow rates, wherein adjusting the gas injection rate comprises sending one or more commands to one or more components associated with the well, wherein the one or more commands are configured to cause the one or more components to adjust the gas injection rate to be within a range of gas injection rates of the second plurality of gas injection rates.
10. The system of claim 9 , comprising a well pad associated with the plurality of wells and the well.
11. The system of claim 10 , wherein the well pad is associated with a reservoir having the hydrocarbons.
12. The system of claim 9 , wherein the data comprises tubing head pressure, tubing head temperature, casing head pressure, casing head temperature, flowline pressure, flowline temperature, choke size, a water fraction amount, an oil fraction amount, an oil density value, a gas density value, a water density value, or any combination thereof.
13. The system of claim 9 , comprising a display configured to visualize the plurality of expected flow rates of hydrocarbons produced from the plurality of wells with respect to the plurality of gas injection rates.
14. The system of claim 9 , wherein the monitoring device is configured to send the plurality of expected flow rates of hydrocarbons produced from the plurality of wells with respect to the plurality of gas injection rates to one or more computing devices.
15. A method, comprising: receiving, via a processor, data associated with one or more properties at a well; determining, via the processor, a plurality of expected flow rates of hydrocarbons produced from the well with respect to a plurality of gas injection rates associated with the well based on a hydrocarbon model configured to estimate the plurality of expected flow rates of hydrocarbons; determining, via the processor, a current flow rate of hydrocarbons at the well based on the data and the hydrocarbon model; determining, via the processor and based on the plurality of expected flow rates, a first range of flow rates that substantially maximizes a flow rate of hydrocarbons at the well, and a second range of gas injection rates that corresponds to the first range of flow rates; determining, via the processor, whether the current flow rate of hydrocarbons at the well is within the first range of flow rates; and adjusting, via the processor, a gas injection rate at the well in response to the current flow rate associated with the well not being within the first range of flow rates, wherein adjusting the gas injection rate comprises sending one or more commands to one or more components associated with the well, wherein the one or more commands are configured to cause the one or more components to adjust the gas injection rate to be within the second range of gas injection rates.
16. The method of claim 15 , wherein the plurality of expected flow rates of hydrocarbons comprises a flow rate of oil and water.
17. The method of claim 15 , wherein the hydrocarbon model is configured to estimate multiphase properties and a watercut level of a flow of hydrocarbons at the well based on the data.
18. The method of claim 15 , wherein the data comprises a water fraction amount, an oil fraction amount, an oil density value, a gas density value, a water density value, or any combination thereof.
19. The method of claim 15 , comprising: plotting a plurality of values on a graph based on a simulation performed using the hydrocarbon model; determining a mathematical function based on the plot; and determining the plurality of expected flow rates of hydrocarbons produced from the well with respect to the plurality of gas injection rates based on the mathematical function.
20. The method of claim 15 , wherein the current flow rate corresponds to a flow rate of oil and water, and the method comprises: determining, via the processor, a second current flow rate of hydrocarbons at the well corresponding to a flow rate of oil based on the data and the hydrocarbon model; determining, via the processor, whether the second current flow rate exceeds a threshold; and adjusting, via the processor, the gas injection rate in response to the second current flow rate not exceeding the threshold.
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October 29, 2015
October 23, 2018
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